WO2018183319A1 - Revêtement isolant de zone de perte de circulation - Google Patents

Revêtement isolant de zone de perte de circulation Download PDF

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Publication number
WO2018183319A1
WO2018183319A1 PCT/US2018/024558 US2018024558W WO2018183319A1 WO 2018183319 A1 WO2018183319 A1 WO 2018183319A1 US 2018024558 W US2018024558 W US 2018024558W WO 2018183319 A1 WO2018183319 A1 WO 2018183319A1
Authority
WO
WIPO (PCT)
Prior art keywords
liner
wellbore
housing
pressure
piston assembly
Prior art date
Application number
PCT/US2018/024558
Other languages
English (en)
Inventor
Shaohua Zhou
Original Assignee
Saudi Arabian Oil Company
Aramco Services Company
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Saudi Arabian Oil Company, Aramco Services Company filed Critical Saudi Arabian Oil Company
Publication of WO2018183319A1 publication Critical patent/WO2018183319A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/003—Means for stopping loss of drilling fluid
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/08—Screens or liners
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/10—Setting of casings, screens, liners or the like in wells
    • E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/10—Setting of casings, screens, liners or the like in wells
    • E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like
    • E21B43/105—Expanding tools specially adapted therefor
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/08—Screens or liners
    • E21B43/086—Screens with preformed openings, e.g. slotted liners
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/10—Setting of casings, screens, liners or the like in wells

Definitions

  • the present disclosure relates to a liner for isolating a wellbore from a lost circulating zone. More specifically, the present disclosure relates to repairing a lost circulation zone in a wellbore with a flexible liner that conforms to a profile of a wellbore sidewall.
  • Hydrocarbon producing wellbores extend subsurface and intersect subterranean formations where hydrocarbons are trapped.
  • the wellbores are usually formed by drilling systems that include a drill string made up of a drill bit mounted to a length of interconnected pipe.
  • a top drive or rotary table above the opening to the wellbore rotates the drill string.
  • Cutting elements on the drill bit scrape the bottom of the wellbore as the bit is rotated and excavate material thereby deepening the wellbore.
  • Drilling fluid is typically pumped down the drill string and directed from the drill bit into the wellbore; the drilling fluid then flows back up the wellbore in an annulus between the drill string and walls of the wellbore. Cuttings are produced while excavating and are carried up the wellbore with the circulating drilling fluid.
  • While drilling the wellbore mudcake typically forms along the walls of the wellbore that results from residue from the drilling fluid and/or drilling fluid mixing with the cuttings or other solids in the formation.
  • the permeability of the mudcake generally isolates fluids in the wellbore from the formation. Seepage of fluid through the mudcake can be tolerated up to a point.
  • cracks in a wall of the wellbore allow free flow of fluid (lost circulation) between the wellbore and adjacent formation. Corrective action is required when the magnitude of the lost circulation compromises well control.
  • the cracks may be from voids in the rock formation that were intersected by the bit, or can form due to large differences in pressure between the formation and the wellbore.
  • LCM heavy concentration lost circulation material
  • MWD downhole measurement while drilling
  • LWD logging while drilling
  • PBL sub a circulating tool, sometimes referred to as a "PBL sub” is often activated at this stage to divert the LCM loaded fluids into the lost circulation zone. If the lost circulation problem is significant, a plug of cement slurry or other material is set in the wellbore adjacent the lost circulation zone, which is then later drilled out.
  • the formation surrounding the wellbore contains natural fractures having such a significant volume that the lost circulation material pumped downhole migrates into the fracture(s) before being set.
  • LCM or bridging material
  • the circulation zones are often at depths requiring a significant time passage before the material can be pumped to the affected zone.
  • a large amount of mud in the wellbore between surface and the depth of the lost circulation zone that can dilute the LCM or bridging material.
  • the large static head existing downhole further destabilizes the lost circulation zone.
  • a method of conducting operations in a wellbore that in one example includes deploying a tubular liner in the wellbore and adjacent a lost circulation zone in the wellbore, urging the liner radially outward into contact with sidewalls of the wellbore, and conforming the liner with a contour of the wellbore by pressing the liner against the sidewalls of the wellbore to remediate the lost circulation zone.
  • the method can also include extending a drill bit through the liner and deepening the wellbore.
  • the material of the liner includes interstitial free steel having a tensile strength of around 30,000 pounds per square inch.
  • the step of urging the liner radially outward can involve pressurizing an inside of the liner.
  • the step of conforming the liner with a contour of the wellbore involves applying a mechanical force against an inner surface of the liner.
  • the step of conforming the liner with a contour of the wellbore optionally includes bulging the liner radially outward into a fracture that extends into a formation surrounding the wellbore.
  • the method can further include providing a protective housing around the liner while deploying the liner into the wellbore.
  • the liner and housing can be a portion of a bottom hole assembly, the method can further involve applying pressure to the bottom hole assembly to project the liner axially from an open end of the housing.
  • the liner has an outer periphery that follows an undulating path when the liner is being deployed downhole.
  • a system for use in conducting operations in a wellbore includes an annular housing, a piston assembly slidably set within the housing, an annular liner detachably attached to the piston assembly and selectively depending into the housing, and a liner shoe on an end of the liner distal from the piston assembly and which defines a sealed space within the liner, so that when pressure is applied to the sealed space, the liner expands radially outward into contact with an inner surface of the wellbore.
  • the liner is made of a material having a tensile strength of about 30,000 pounds per square inch, so that by applying pressure to the sealed space the liner conforms to a profile of sidewalls of the wellbore, and bulges into fractures that extending from the sidewalls and into a formation that surrounds the wellbore.
  • An expander can optionally be included and which selectively expands into contact with the liner to mold the liner against sidewalls of the wellbore.
  • an end of the housing is in communication with a pressure source, so that when pressure is supplied from the pressure source, the piston is slidingly urged within the housing to deploy the liner from within the housing.
  • a tubular member can be included that has an end attached to the piston assembly and extending into the liner, and a burst orifice on the tubular member, so that when pressure is supplied to the tubular member that exceeds a burst pressure of the burst orifice, pressure is applied to an inside of the liner that radially expands the liner into conforming contact with sidewalls of the wellbore.
  • a dog assembly mounted onto the piston assembly, and that projects radially outward into a profile formed on an inner circumference of the housing.
  • the dog assembly includes a dog member and a resilient member that urges the dog member into the profile.
  • a pressure actuated rod is set in the housing that selectively moves adjacent the dog assembly thereby rotationally affixing the housing and the piston assembly.
  • Figures 1 - 3 are side sectional views of example steps of assembling an embodiment of a bottom hole assembly for deploying a liner downhole.
  • Figures 4A - 4G are side sectional views of example steps of deploying the liner of Figure 1 in a wellbore and with the bottom hole assembly.
  • Figure 4H is a side sectional view of an example of deepening the wellbore past the liner.
  • Figures 5A - 5C are side sectional views of an example of operation of a piston locking mechanism for use with the bottom hole assembly of Figure 3.
  • Figure 6 is an axial view of an example of the bottom hole assembly and taken along lines 6-6 of Figure 5C.
  • Figures 7A and 7B are side partial sectional views of an example of operational steps of an expander for use with the bottom hole assembly of Figure 3.
  • Figures 8A and 8B are side partial sectional views of an example of operational steps of an alternate embodiment of an expander for use with the bottom hole assembly of Figure 3.
  • Figure 9 is an axial sectional view of an example of the bottom hole assembly of Figure 3 and taken along lines 9-9.
  • Figure 1 shows in a side partial sectional view one example of a housing 10 being inserted into a wellbore 12, where wellbore 12 intersects a subterranean formation 13. Housing 10 is shown being suspended in wellbore 12 on slips 14. Slips 14 are schematically shown supported on a rig floor 16 which is shown adjacent an opening of wellbore 12. An example of a liner 18 is shown being landed within the housing 10 and supported on hand slips 20.
  • housing 10 and liner 18 are each annular members with a curved outer circumference, an axial bore within, and having a length greater than a diameter.
  • housing 10 has a length greater than a length of liner 18.
  • the hand slips 20 are in turn suspended above the wellbore 12 on support 22, that in one example can be a false rotary table.
  • An end of liner 18 projecting out of wellbore 12 is shown coupled to a piston assembly 24 that provides a sealing interface on this end of liner 18.
  • the example of the piston assembly 24 shown is a generally cylindrical member with an outer diameter greater than an outer diameter of liner 18 and which is substantially the same as an inner diameter of housing 10.
  • a sealing interface can be formed along where the outer periphery of piston assembly 24 contacts the inner diameter of housing 10.
  • a deployment system 26 Shown disposed within liner 18 is an example of a deployment system 26 that includes a body 28 and with an expander 30 mounted to body 28 at an axial location distal from piston assembly 24.
  • body 28 of deployment system 26 has an annular configuration and is generally coaxial with liner 18.
  • a slip sub 32 is integrally formed on body 28 to allow for selective changes of axial length of body 28.
  • a liner shoe 34 is shown mounted on an end of liner 18 distal from piston assembly 24.
  • liner shoe 34 is a cup like member with an open end coupled with an end of liner 18 distal from piston assembly 24.
  • the liner shoe 34 and piston assembly 24 define a sealed space 35 inside of liner 18.
  • FIG. 2 shown in a partial side sectional view is where the piston assembly 24 is inserted into housing 10 so that the attached liner 18 is inserted deeper into housing 10.
  • the hand slips 20 and support 22 of Figure 1 have been removed thereby allowing liner 18 and piston assembly 24 to slide axially within housing 10.
  • shear pins 26 that couple housing 10 to piston assembly 24, and that project radially through a sidewall of housing 10 and into piston assembly 24.
  • a piston head 38 makes up the section of the piston assembly 24 intersected by shear pins 36.
  • Figure 3 shows in a side partial sectional view a schematic example of a cross over 40 being mounted to an end of housing 10 distal from liner shoe 34.
  • Cross over 40 provides a mean for connecting the housing 10 and liner 18 to a drill pipe 42.
  • the assembly of the housing 10, piston assembly 24, and deployment system 26 define an example of a bottom hole assembly 44 as will be described in more detail below is used for remediating a lost circulation zone within wellbore 12.
  • the addition of the drill pipe 42 provides a means for deploying and retrieving the bottom hole assembly 44 into and from wellbore 12.
  • FIG. 4A Depicted in a side partial sectional view in Figure 4A is an example of the bottom hole assembly 44 being deployed on drill pipe 42 within wellbore 12.
  • an upper end of the drill pipe 42 is supported from a drilling rig 46 that is set over an opening of the wellbore 12.
  • the wellbore 12 includes a vertical section 48 that is adjacent the opening of the wellbore 12, and a deviated section 50 that extends generally horizontally within formation 13 from an end of vertical section 48.
  • fractures 52 are shown projecting radially outward from wellbore 12 into formation 13. These fractures 52, which can occur naturally or through a fracking process, define an area where fluid in the wellbore 12 flows freely into formation 13 thereby forming a loss circulation zone 54.
  • deploying the liner 18 adjacent a loss circulation zone 54 can constitute a barrier for remediating fluid losses from wellbore 12.
  • FIG. 4B Illustrated in Figure 4B is a side partial sectional view of an example of another step of the wellbore operation described herein.
  • the piston assembly 24, deployment system 26, and liner 18 are shown having been urged axially outward from within housing 10 and adjacent to the loss circulation zone 54.
  • Force for axially deploying the liner 18 from housing 10 can optionally be provided by a pressure source 56 shown on surface 57 outside an opening of wellbore 12.
  • pressure source 56 is in communication with the drill pipe 42 via a wellhead assembly 58 on surface 57.
  • Line 60 communicates pressurized fluid from pressure source 56 to wellhead assembly 58 that is subsequently transferred to drill pipe 42 and introduced into housing 10.
  • FIG. 4C Shown in side sectional view in Figure 4C is that the fluid from fluid source 56 has entered into the body 28 of deployment system 26 and exceeded a set pressure of rupture disks 64 shown formed at various locations along a sidewall of body 28.
  • fluid F exits the body 28 through the rupture disk 64, and enters into the sealed space 35 defined within liner 18 and bounded on axial ends by piston assembly 24 and liner shoe 34.
  • the pressure of the fluid F within sealed space 35 causes the liner 18 to project radially outward and into contact with the sidewalls of wellbore 12.
  • slip sub 32 of Figure 4D operates to allow the body 28 to contract and expand, thereby compensating for axial changes in length of liner 18 as the radius of liner 18 changes with the application of the pressure within the sealed space 35.
  • body 28 is contracted as the length of liner 18 contracts in response to its expanding radius.
  • slip sub 32 further maintains a pressure seal internally, and is capable of carrying tubular weight of the below section via a stop ring (not shown).
  • Slip sub 32 is optionally formed from overlapping tubular with a fluid filled chamber, where the inner member has elastomer seal rings at its end, and is slidable on the inner surface if the outer member
  • An advantage of the technique employed for placing the liner is that the inner diameter of the wellbore 12 after having been remediated and with the liner 18 set and in place, remains substantially the same as that prior to remediation. As such, the presence of liner 18 as shown set and deployed in the example of Figure 4D does not hinder subsequent operations within the wellbore 12 as the diameter of the wellbore 12 is not diminished.
  • the material of the liner 18 selectively chosen to be sufficiently pliable to be deformed under the applied pressure of the fluid F, and substantially conform to the contours 68 within wellbore 12.
  • material of the liner 18 is also chosen to have a sufficient strength so that the liner 18 maintains its structural integrity while and after being deformed so that the barrier between wellbore 12 and formation 14 is sustained to allow for normal operation of the wellbore 12.
  • material for the liner 18 includes a highly deformable metal, such as a low yield grade of steel, and in an alternative has an expansion ratio that is at least around 50%.
  • One example material can include interstitial free (“IF") steel, such as that having ultra-low carbon content.
  • IF interstitial free
  • ultra-low carbon content is achieved by removing carbon monoxide, hydrogen, nitrogen, and other gasses during steelmaking through a vacuum degassing process.
  • the material for liner 18 can include mild steel, such as a mild steel with a relatively simple ferritic microstructure, low carbon content, and minimal alloying elements so that it is soft.
  • Example tensile strengths of the IF steel range up to an include about 30,000 pounds per square inch, and are up to and about 40,000 pounds per square inch for the mild steel.
  • constituents of the IF steel include carbon, silicon, manganese, phosphorus, sulfur, chromium, aluminum, nitrogen, vanadium, nickel, titanium, and iron.
  • Example mass percentages of constituents of the IF steel include carbon at 0.0020, silicon at 0.010, manganese at 0.170, phosphorus at 0.0120, sulfur at 0.080, chromium at 0.040, aluminum at 0.041, nitrogen at 0.0027, vanadium at 0.005, nickel at 0.020, titanium at 0.072, with the balance being iron.
  • low carbon steel describes steel having a carbon content of from about 0.05 percent by weight up to about 0.3 percent by weight. In one alternative, low carbon steel describes steel having a carbon content of up to about 0.05 weight percent by weight.
  • Liners 18 formed from material in accordance with that described herein can be used in pressurized formations where the pressure differential is up to at least around 1000 to 1500 pounds per square inch, and with a potential collapse pressure that ranges up to around 300 to 500 pounds per square inch.
  • An advantage of forming the liner 18 from steel, with some inherent strength, is the better wear resistance to the expected friction caused by drilling BHA and drill string rotation, hence better enable continued drilling of the remained wellbore lateral to the planned well total depth, rather other alternative choices of soft material, such as aluminum, brass, composite material, and the like.
  • FIG. 4E Shown in Figure 4E is a side partial sectional view of an example step of drawing the bottom hole assembly 44 out from wellbore 12 after having separated the liner 18 from the remaining portion of bottom hole assembly 44.
  • An open end 69 of the liner 18 previously connected to the piston assembly 24 is shown set radially inward and spaced away from the sidewall of the wellbore 12.
  • the spacing between the open end 69 of the liner 18 and sidewall of the wellbore 12 is addressed in the example of Figure 4F.
  • the expander 30 radially expands into contact with the open end 69 of liner 18 to urge the end 69 into conforming contact with the sidewall of the wellbore 12.
  • An advantage of a bottom hole assembly 44 having an expander 30 is the ability to maintain the entire length of the liner 18 at substantially the same contour and shape of the sidewalls of the wellbore 12. As such, the possibility of contacting the open end 69 of the liner 18 during subsequent wellbore operations is diminished by employing the use of the expander 30.
  • the expander 30 can be operated to apply a radial outward force along the entire length of the liner 18 to better secure the liner 18 in the wellbore 12, and reshape the liner 18 to approximate the contour of the sidewall of the wellbore 12.
  • FIG. 4G Illustrated in a side partial sectional view in Figure 4G is an example of the liner 18 being set and deployed within wellbore.
  • the liner 18 is formed from a material that can withstand the normal operating pressures within wellbore 12 and prevent flow of fluid of wellbore 12 into the fractures 52 or other portions of the lost circulation zone 54.
  • the liner shoe 34 of Figure 4G can be removed with a drill bit 70 shown mounted on a lower end of a drill string 42.
  • a top drive 72 shown within drilling rig 46 provides rotational force to the drill pipe 42.
  • other means of rotating drill pipe 42 can be employed for rotating the bit 70 and thereby removing the liner shoe 34 of Figure 4G.
  • FIG. 5A through 5C illustrate one example operation of a mechanism for latching together the piston assembly 24 and housing 10.
  • the piston assembly 24 is shown having an annular pedestal 74 that couples generally coaxially on a side of piston head 38 that faces liner 18.
  • Pedestal 74 has a pin end 76 on its lower terminal end which is distal from piston head 38.
  • Pin end 76 connects with a box end 78 shown provided on an upper end of liner 18 and proximate the pin end 76.
  • Threads are provided on the pin end 76 and box end 78 that when engaged form a threaded connection 80 which provides releasable connectivity between piston assembly 24 and liner 18.
  • dog assemblies 82 mounted on an outer wall of pedestal 74.
  • the dog assemblies 82 include dog members 84 that are in contact with an inner wall of housing 10, and resilient members 86 between dog members 84 and an outer surface of pedestal 74.
  • the resilient members 86 urge the dog members 84 radially outward.
  • Rollers 88 are optionally provided on a surface of dog members 84 adjacent an inner surface of housing 10 which facilitate sliding of the piston assembly 24 within housing 10.
  • Optional seals 90 are shown that circumscribe piston head 38 and which define a pressure barrier between the piston head 38 and inner surface of housing 10.
  • FIG. 5A Further illustrated in Figure 5A are pressure disks 92 that are disposed in cavities 94 formed in a sidewall of housing 10. Cavities 94 are in communication with a bore 96 shown extending axially through housing 10. In the example of Figure 5A, the cavities 94 are on a side of piston head 38 opposite from the dog assemblies 82.
  • Axial passages 98 extend from a side of cavities 94 through sidewall of housing 10. Rods 100 are set in the passages 98 and which each have a length similar to a length of its corresponding passage 98.
  • the passages 98 terminate in a channel 102 shown formed in the sidewall of the inner surface of housing 10, and which extends radially outward from bore 96.
  • channel 102 extends the full inner circumference of housing 10.
  • dog assemblies 82 are between cavities 94 and channel 102.
  • Channel 102 is optionally sized with an axial length to accommodate piston assemblies 82 within.
  • FIG 5B shown in a side partial sectional view is an example of pressurizing bore 96 so that piston assembly 24 moved axially within housing 10 in a direction away from cavities 94 and pressure disk 92. Sufficient axial movement of the piston assembly 24 urges the dog assemblies 82 into registration with channel 102. When registered, the dog members 84 are urged radially outward and into channel 102 by the presence of the resilient members 86.
  • resilient members 86 include springs, pneumatics, as well as elastomeric members.
  • the rods 100 that are able to enter the channel 102 are adjacent lateral edges of the dog assemblies 82 of Figure 5B thereby providing a rotational coupling between the housing 10 and piston assembly 24.
  • flow is ported through piston assembly 24 and into body 28 through a bore in the piston.
  • FIG. 6 illustrated in an axial view and taken along line 6-6 of Figure 5C, are the rods 100 adjacent the lateral sides of the dog assemblies 82.
  • rods 100A shown in a dashed outline represent position of rods 100A when rods 100A are spaced axially away from channel 102, such as in Figure 5B.
  • rods 100A are urged axially and into channel 102, and as illustrated by rods 100 having the solid outline form.
  • the pedestal 74 can be disconnected from liner 18 by applying rotational force A R to housing 10 to decouple the threaded connection 80 of Figure 5A.
  • Figure 7A and 7B show in a side partial sectional view an example of deploying the expander 30 radially outward from deployment system 26.
  • the expander 30 includes a cylindrical roller 106 that is mounted in orientation that is generally parallel within axis ⁇ of body 28. Roller 106 mounts within a carriage 108 and is rollable with respect to carriage 108. Slots 110 are shown formed within an outer surface of body 28 and strategically formed to receive the carriage 108 and roller 106.
  • a bore 104 projects axially within body 28 and which is selectively in fluid communication with drill pipe 42 of Figure 4B.
  • a port 112 extends from an outer wall of bore 104 and into communication with an inner radial portion of slots 110.
  • a ball 114 has been deployed downhole and which lands within a ball seat 116 formed within bore 104 and defined where the radius of bore 104 projects radially inward to have a radius less than that of ball 114.
  • ball seat 116 ball 114 defines a flow barrier within bore 104.
  • pressure within slots 110 is increased by adding a pressurizing fluid to bore 104.
  • Pressurizing slots 110 in turn urges carriages 108 and rollers 106 radially outward.
  • FIG. 7B Further illustrated in Figure 7B is how an outer periphery of roller 106 extends past its position of Figure 7A and to a designated diameter 118.
  • the designated diameter 118 is at a location that by contacting the rollers 106 and their configuration of Figure 7B with the inner surface of liner 18 of Figure 4F in turn urges liner 18 against sidewalls of wellbore 12 thereby conforming liner against wellbore 12.
  • FIG. 8A and 8B An alternative example of the expander 30 is shown in partial side sectional views in Figures 8A and 8B.
  • a packer 120A is provided in carriage 108A that is set in slots 110A.
  • the packer 120A can optionally be formed by elastomeric material and include a chamber 122A within that is in fluid communication with bore 104A via port 112A and inlet 124A.
  • a ball 114A is shown dropped into a ball seat 116A of Figure 8B so that subsequently pressurizing the bore 104A communicates pressurized fluid into chamber 122A via port 112A and inlet 124A.
  • the chamber 122A is filled with pressurized fluid so that the outer diameter of packer 120A is substantially in line with the designated diameter of 118A and for being put into conforming contact with liner 18.
  • Figure 9 shows in an axial sectional view an example of liner 18A and set within housing 10 and being deployed within a wellbore 12.
  • the liner 18A has a cross section that is undulating and so that it can fit within housing 10 when in its unexpanded state.
  • a dashed circular line represents an outer diameter of the deployed or set liner 18Ai and which projects outside of housing 10.
  • the liner 18A can be twisted into a helical configuration and with the undulations projecting in a helix like fashion along the length of the liner 18 A.
  • the steps involved are as follows.
  • the bottom hole assembly 44 is deployed into the wellbore 12 with the protective housing 10, and supported with casing slips 14 at rig floor 16.
  • the liner 18 is supported with hand slips 20 on top of a false rotary table (not shown).
  • Deployment system 26 with its expander 30 is lowered into piston assembly 24 is connected to top of liner 18.
  • the connection 80 between piston assembly 24 and liner 18 is a left hand thread.
  • An advantage of the threaded connection 80 is increased sealing capability across the connection 80
  • Liner 18 is lowered and shear pins 36 are installed to hang the liner 18 in the protective housing 10.
  • Piston assembly 24 engages a locking mechanism provided with housing 10 to axially couple piston assembly 24 and liner 18 with housing 10 and suspend further axial movement between piston assembly 24 and housing 10.
  • Inside of body 28 is pressurized to a pressure exceeding a burst pressure of burst disks 64 installed on sidewalls of body 28.
  • Flowing pressurized fluid through burst disks 64 and into sealed space 35 inflates/radially expands liner 18. Maintain pressure inside sealed space 35 for a period of time, such as for example about 30 minutes, to radially expand liner 18 so that the liner 18 conforms to contours along sidewall of wellbore 12. Pressure in drill pipe 42, body 28, and sealed space 35 is bled off at surface.
  • a flow-check can be performed, that in one example is well static to determine if flow is still being lost in lost circulation zone 54. If losses are not cured, then reintroduce pressure into sealed space via drill pipe 42, and move drill pipe 42 slightly up or down to enable a better contact of ends of liner 18 with sidewalls of wellbore 12. Also draw drill pipe 42 slightly upward to check if the liner 18 is fully expanded and anchored across the lost circulation zone 54. Decouple bottom hole assembly 44 from liner 18, and draw drill pipe 44 upward so that the expander 30 is below the open end 69 of liner 18. Rotating the work string clockwise decouples the bottom hole assembly 44 from liner 18 due to the left hand threaded connected between liner 18 and assembly 14.
  • a second ball 114 which has a larger diameter than the first ball (not shown) and land ball 114 in ball seat 116 to create flow barrier.
  • a drift run can also be optionally performed.
  • a drift run includes a test run to check the condition of the expanded flexible liner, in one operational embodiment, the expander 30 is run to the bottom setting depth to ensure sufficient space available to subsequent drilling pass-through. Bottom hole assembly 44 can be removed from wellbore 12, liner shoe 34 is drilled out, and drilling continued.
  • Advantages of the system and method described herein include the protective housing 10 which significantly reduces risk of damage to the liner 18 while being deployed downhole.
  • Design of the liner 18 provides for a simple and quick installation and setting. Liner 18 can also be quickly removed by milling in case of failure to remediate the lost circulation zone 54.
  • the operating procedure is simple and straightforward, and easy to verify the liner 18 expansion and anchor before releasing running tool system.
  • the mechanical solution provided herein does not require special LCM or cement, hence less formation damage (if loss zone is inside reservoir).
  • Deployment of the bottom hole assembly 44 also allows for circulation and rotation while running in hole; which can be accomplished like other operations while drilling, and which includes circulation of fluid from surface within drill pipe 42, down to the piston face, the inner string within the liner 18 and through liner shoe 34 and returning to surface in the annulus between the string and the wellbore 12.
  • drill pipe 42 is rotated, such as from a rotary table or top drive on surface (not shown).
  • a cross-over to the protective housing 10 is optionally included and that has a threaded connection for rotating the housing 10 without subjecting the flexible liner 18 to rotational stress and strain. Incorporating a roller expander to assist fully expanding the top of flexible skin liner for a better seal and drift same or whole flexible liner post expansion, so it is one-trip deployment system.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)
  • Geophysics (AREA)

Abstract

L'invention concerne un procédé et un système (26) permettant de remédier à une zone de perte de circulation (54) dans un puits de forage (12). Un revêtement souple (18) est déployé à proximité de la zone de perte de circulation (54) qui bloque la communication fluidique entre le puits de forage (12) et la formation environnante (13). Le matériau de revêtement (18) a une limite d'élasticité et une résistance à la traction nominales, de telle sorte que, en réponse à la pression appliquée dans le puits de forage (12), le revêtement (18) se fléchit et s'adapte aux contours du puits de forage (12). Le revêtement (18) reste intact pendant la déformation pour maintenir la barrière d'écoulement entre le puits de forage (12) et la formation (13). Le revêtement (18) est placé dans le puits de forage (12) avec un ensemble fond de trou (44) qui comprend un boîtier externe (10) pour protéger le revêtement (18) pendant le déplacement de fond de trou. Le tube de forage (42) peut être utilisé pour le déploiement de l'ensemble de fond de trou (44), et pour le transport de fluide sous pression pour la pose du revêtement (18). Un détendeur (30) est inclus avec l'ensemble de fond de trou (44) pour la mise en conformité mécanique du revêtement (18) aux parois latérales de puits de forage.
PCT/US2018/024558 2017-03-27 2018-03-27 Revêtement isolant de zone de perte de circulation WO2018183319A1 (fr)

Applications Claiming Priority (2)

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US15/469,996 2017-03-27
US15/469,996 US10689926B2 (en) 2017-03-27 2017-03-27 Lost circulation zone isolating liner

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WO2018183319A1 true WO2018183319A1 (fr) 2018-10-04

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